Liquid aeration plunger

ABSTRACT

An improved plunger lift apparatus having an internal orifice, nozzles and exit apertures. The present invention relates to an improved plunger lift apparatus for the lifting of formation liquids in a hydrocarbon well. More specifically the improved plunger consists of a plunger apparatus that operates to propel one or more jets of gas through one or more internal orifices and/or nozzles, out through an aperture and into the liquid load formation, thereby providing a momentum transfer of the gas into the liquid load and causing a gaseous and turbulent aeration to the formation during lift. This action allows a large liquid formation load to be carried to the well top by the plunger at an increased level of efficiency resulting in an improved well productivity level.

FIELD OF THE INVENTION

The present invention relates to an improved plunger lift apparatus for the lifting of formation liquids in a hydrocarbon well. More specifically the improved plunger consists of an internal nozzle plunger apparatus that operates to propel one or more jets of gas through an internal aperture and into the liquid load formation. This provides a momentum transfer of the gas into the liquid load and causing a gaseous aeration to the formation during lift, allowing a large liquid loading to be carried to the well top by the plunger at an increased level of efficiency.

BACKGROUND OF THE INVENTION

A plunger lift is an apparatus that is used to increase the productivity of oil and gas wells. Nearly all wells produce liquids. In the early stages of a well's life, liquid loading is usually not a problem. When rates are high, the well liquids are carried out of the well tubing by the high velocity gas. As the well declines, a critical velocity is reached below which the heavier liquids do not make it to the surface and start to fall back to the bottom, exerting back pressure on the formation and loading up the well. A basic plunger system is a method of unloading gas in high ratio oil wells without interrupting production. In operation, the plunger travels to the bottom of the well where the loading fluid is picked up by the plunger and is brought to the surface removing all liquids in the tubing. The plunger also helps keep the tubing free of paraffin, salt or scale build-up.

A plunger lift system works by cycling a well open and closed. During the open time a plunger interfaces between a liquid slug and gas. The gas below the plunger will push the plunger and liquid to the surface. This removal of the liquid from the tubing bore allows an additional volume of gas to flow from a producing well. A plunger lift requires sufficient gas presence within the well to be functional in driving the system. Oil wells making no gas are thus not plunger lift candidates.

A typical installation plunger lift system 100 can be seen in FIG. 1. Lubricator assembly 10 is one of the most important components of plunger system 100. Lubricator assembly 10 includes cap 1, integral top bumper spring 2, striking pad 3, and extracting rod 4. Extracting rod 4 can be employed depending on the plunger type. Within lubricator 10 is plunger auto catching device 5 and plunger sensing device 6.

Sensing device 6 sends a signal to surface controller 15 upon plunger 200 arrival at the well top. Plunger 200 can be the plunger of the present invention or other prior art plungers. Sensing the plunger is used as a programming input to achieve the desired well production, flow times and wellhead operating pressures.

Master valve 7 should be sized correctly for the tubing 9 and plunger 200. An incorrectly sized master valve 7 will not allow plunger 200 to pass through. Master valve 7 should incorporate a full bore opening equal to the tubing 9 size. An oversized valve will allow gas to bypass the plunger causing it to stall in the valve.

If the plunger is to be used in a well with relatively high formation pressures, care must be taken to balance tubing 9 size with the casing 8 size. The bottom of a well is typically equipped with a seating nipple/tubing stop 12. Spring standing valve/bottom hole bumper assembly 11 is located near the tubing bottom. The bumper spring is located above the standing valve and can be manufactured as an integral part of the standing valve or as a separate component of the plunger system. It is designed to protect the tubing from plunger impact in the absence of fluid. Fluid 17 would accumulate on top of plunger 200 to be carried to the well top by plunger 200.

Surface control equipment usually consists of motor valve(s) 14, sensors 6, pressure recorders 16, etc., and an electronic controller 15 which opens and closes the well at the surface. Well flow ‘F’ proceeds downstream when surface controller 15 opens well head flow valves. Controllers operate on time and/or pressure to open or close the surface valves based on operator-determined requirements for production. Additional features include: battery life extension through solar panel recharging, computer memory program retention in the event of battery failure and built-in lightning protection. For complex operating conditions, controllers can be purchased that have multiple valve capability to fully automate the production process.

FIG. 2 (prior art) is a side view of plunger mandrels with various plunger sidewall geometries existing within prior art. An internal mandrel orifice 44 may or may not be present in prior art plungers, but is required for the present invention and will be described below. All mandrels have male end sleeves 41 with threaded male areas 42 used to attach various top and bottom ends, which will be described below in FIG. 3. All geometries described can be found in present industrial offerings. The aforementioned sidewall geometries are described as follows:

-   -   A. Plunger mandrel 20 has solid ring 22 sidewall geometry. Solid         sidewall rings 22 can be made of various materials such as         steel, poly materials, Teflon®, stainless steel, etc. Inner cut         groves 30 allow sidewall debris to accumulate when a plunger is         rising or falling.     -   B. Plunger mandrel 80 has shifting ring 81 sidewall geometry.         Shifting rings 81 sidewall geometry allow for continuous contact         against the tubing to produce an effective seal with wiping         action to ensure that most scale, salt or paraffin is removed         from the tubing wall. Shifting rings 81 are all individually         separated at each upper surface and lower surface by air gap 82.     -   C. Pad plunger mandrel 60 has spring-loaded interlocking pads 61         in one or more sections. Interlocking pads 61 expand and         contract to compensate for any irregularities in the tubing,         thus creating a tight friction seal.     -   D. Brush plunger mandrel 70 incorporates a spiral-wound,         flexible nylon brush 71 surface to create a seal and allow the         plunger to travel despite the presence of sand, coal fines,         tubing irregularities, etc.     -   E. Flexible plungers (not shown) are flexible for coiled tubing         and directional holes, and can be used in straight standard         tubing as well.

FIG. 3 (prior art) is a side view fully assembled plungers with fishing neck ‘A’ top geometry and various aforementioned plunger sidewall geometries. It also has a bottom striker 46 added for hitting the well bottom. If retrieval is required, a spring loaded ball within a retriever and protruding inside its surface would fall outside and onto the prior art API internal fishing neck ‘A’ at the top of the plunger, wherein the ball would spring outward to capture and retrieve the plunger if, and when, necessary.

Recent practices toward slim-hole wells that utilize coiled tubing also lend themselves to plunger systems. With the small tubing diameters, a relatively small amount of liquid may cause a well to load-up, or a relatively small amount of paraffin may plug the tubing.

Plungers use the volume of gas stored in the casing and the formation during the shut-in time to push the liquid load and plunger to the surface when the motor valve opens the well to the sales line or to the atmosphere. To operate a plunger installation, only the pressure and gas volume in the tubing/casing annulus is usually considered as the source of energy for bringing the liquid load and plunger to the surface.

The major forces acting on the cross-sectional area of the bottom of the plunger are:

-   -   The pressure of the gas in the casing pushes up on the liquid         load and the plunger.     -   The sales line operating pressure and atmospheric pressure push         down on the plunger.     -   The weight of the liquid and the plunger weight pushes down on         the plunger.     -   Once the plunger begins moving to the surface, friction between         the tubing and the liquid load acts to oppose the plunger.     -   In addition, friction between the gas and tubing acts to slow         the expansion of the gas.

In certain wells, the liquid loading is relatively large and causes the plunger lift to operate at a relatively slow rate. A well's productivity is impacted by the lift rate and a heavy liquid load formation can be a major factor in effecting a well's productivity.

What is needed is a plunger lift apparatus than can more effectively lift a heavy liquid load, one that will carry a heavy liquid load at a faster rise velocity to the well top. The apparatus of the present invention provides a solution to these problems.

SUMMARY OF THE INVENTION

The main aspect of the present invention is to provide a plunger apparatus that can have an extended load capacity in carrying a liquid formation to the well top.

Another aspect of the can will increase lift velocity of the plunger and liquid load when rising to the well top.

Another aspect of the present invention is to provide a means for transferring momentum from gas at the well bottom through a gas jet and onto a liquid formation to assist with overall plunger lift load.

Another aspect of the present invention is to provide a plunger that can be used with any existing plunger sidewall geometry.

Other aspects of this invention will appear from the following description and appended claims, reference being made to the accompanying drawings forming a part of this specification wherein like reference characters designate corresponding parts in the several views.

The present invention is a plunger mechanism apparatus having one or more internal orifices that allows a transfer of momentum from the gas at the well bottom into the liquid load formation during plunger lift via jetting of the gas. This allows the plunger to carry a heavy liquid load to the well top in an improved manner, increasing the liquid load capacity and/or allowing for a faster rise velocity with a fixed liquid load, both as compared to prior art. The result is an increase in well productivity for wells with high liquid loads.

The present invention comprises a plunger lift apparatus having a top section with an inner longitudinal orifice and having one or more nozzle exit apertures (orifices) at or near its upper surface. The design of the outer geometry is typically a standard American Petroleum Institute (API) fishing neck, or other designs. The plunger also has a mandrel mid section allowing for the various sidewall geometries, and an internal orifice throughout its length and a lower section having an internal longitudinal orifice. All the sections connect together forming the liquid aeration plunger of the present invention which has a conduit allowing gas to pass up through an internal plunger conduit (orifice), up through an internal nozzle, and out through one or more apertures thereby transferring momentum from a gas to a liquid load providing a lift assist and causing gaseous aeration of the liquid load.

When the surface valves open to start the lift process, down hole pressure will result in gas being forced through the plunger nozzles, exiting one or more apertures into the liquid formation transferring momentum from the jetting gas onto the liquid formation. The momentum transfer causes aeration and results in a liquid formation lift assist allowing the plunger to carry a heavier liquid load to the well top and/or carry a fixed liquid load at an improved velocity as compared to a non-aerated liquid formation. Applying a soapy mixture down to the well bottom between the well casing and tubing can assist the aeration process by allowing a higher surface tension in the gaseous bubbles formed within the liquid formation.

An additional embodiment of the present invention incorporates a nozzle type aerator in a bypass plunger design, employing the same basic concept of momentum transfer and gaseous aeration of the liquid formation.

The liquid aeration plunger of the present invention allows for improved productivity in wells that have large levels of liquid formation. It allows for a more efficient lift of high liquid loads both increasing the lift capacity and also the lift velocity by aerating the liquid load during plunger lift. The liquid aeration plunger is easy to manufacture, and easily incorporates into the design into existing plunger geometries.

BRIEF DESCRIPTION OF THE DRAWINGS

FIG. 1 (prior art) is an overview depiction of a typical plunger lift system installation

FIG. 2 (prior art) is a side view of plunger mandrels with various plunger sidewall geometries existing within prior art.

FIG. 3 (prior art) is a side view fully assembled plungers with fishing neck top geometry and various plunger sidewall geometries.

FIG. 4 is a cross-sectional view of upper nozzle section of the liquid aeration plunger of the present invention showing the internal orifice, nozzles, and nozzle exit apertures.

FIG. 5 is an isometric cut side view of the liquid aeration plunger of the preferred embodiment of the present invention.

FIG. 6 is a side cross-sectional cut view of the liquid aeration plunger of the present invention during plunger lift.

FIG. 7 (prior art) shows side views of variable orifice bypass valve (VOBV) with various aforementioned sidewall geometries.

FIG. 8A (prior art) is a side cross-sectional view of a variable orifice bypass valve assembly with the actuator rod shown in the open (or bypass) position.

FIG. 8B (prior art) is a side cross-sectional view of a variable orifice bypass valve assembly and similar to FIG. 8A but with the actuator rod shown in its closed (no bypass) position.

FIG. 9 is a top view of a grooved actuator rod.

FIGS. 9A, 9B are an additional embodiment of the present invention for a liquid aeration bypass plunger showing cross sectional views of examples of possible modifications of an actuator rod for a bypass valve assembly to allow for small gas exit aperture(s) when in its closed position.

FIG. 9C is a cross sectional view of FIG. 9.

FIGS. 10, 10A, 10B are side cross-sectional views of the additional embodiment of the present invention for a liquid aeration bypass plunger showing various modified actuator rods within a bypass valve assembly.

Before explaining the disclosed embodiment of the present invention in detail, it is to be understood that the invention is not limited in its application to the details of the particular arrangement shown, since the invention is capable of other embodiments. Also, the terminology used herein is for the purpose of description and not of limitation.

DETAILED DESCRIPTION OF THE INVENTION

Referring now to the drawings, the present invention is a liquid aeration plunger 2000 apparatus (FIG. 5) having an upper nozzle section 200 (FIGS. 4,5) with an inner longitudinal orifice with one or more nozzle exit apertures at or near its upper surface. The design of the outer geometry of the upper surface is typically a standard American Petroleum Institute (API) fishing neck, or other designs. The plunger has a mandrel mid section to allow for various aforementioned sidewall geometries (FIG. 2), an internal orifice throughout its length and a lower section 46A (FIG. 5) with an internal longitudinal orifice.

All the sections connect together to allow the gaseous aeration of the liquid load by the plunger of the present invention. When the surface valves open to start the lift process, down hole pressure will cause gas to be forced through the plunger nozzles, exiting from apertures into the liquid load thereby transferring momentum from the gas to the liquid and producing a turbulent and gaseous aeration of the liquid. This action will allow a more efficient lift of the liquid formation to the well top.

FIG. 4 is a cross-sectional view of upper nozzle section 200 of the liquid aeration plunger of the present invention showing internal orifices and nozzle exit apertures. The upper external end is a prior art fishing neck ‘A’ design. Upper nozzle section 200 is shown with four nozzle exit apertures 52 dispersed evenly around its upper surface, with each exiting at about 45° to the liquid formation boundary. Upper nozzle section 200 easily connects to any mandrel (ref. FIG. 2) via internal female sleeve orifice 58 mating to the male end sleeve 41 (FIG. 2) and threaded internal female sleeve orifice 56 mating with threaded male area 42 (FIG. 2). Upper nozzle section internal through-orifice 54 connects to each nozzle exit orifice 53 and also connects to internal female sleeve orifices 56, 58. It should be noted that the nozzle quantity, location, size and other designs are offered by way of example and not limitation. Although four nozzle orifices 53 and aperture exits 52 are shown, each at about a 450 cut angle into upper section orifice 54, the present invention is not limited to the design shown. Other nozzle designs could easily be incorporated to encompass one or more exit nozzle apertures, various size nozzle holes, various angles, etc.

The upper end has at least one exit orifice has a total cross sectional area in the range of about 0.25% to 10% of the maximum plunger cross sectional area. Typically, the smallest range of the cross sectional area of either the lower end apertures or the upper end apertures or the internal longitudinal orifice is about 3.22 mm² to 32.3 mm² (0.005 to 0.05 inch²). In FIG. 4 the four nozzle orifices are each typically about 2.36 mm (0.093″) in diameter, combining to about 17.4 mm² (0.027 inch²) of area as compared to the outside diameter of a typical plunger of about 47 mm (1.85″) or about 1735 mm² (2.69 inch²).

FIG. 5 is an isometric cut side view of entire liquid aeration plunger 2000 of the preferred embodiment of the present invention. Each section; upper nozzle section 200; solid wall plunger mandrel 20; and lower section 46A; are shown having interconnected internal orifices. Lower section 46A is modified from present art by providing lower section internal orifice 44A. Lower section 46A attaches to mandrels male end sleeves 41 and threaded male areas 42, previously shown in FIG. 2.

Liquid aeration plunger 2000 functions to allow gas to pass into lower section 46A at lower entry aperture 48, up through lower section internal orifice 44A, through internal mandrel orifice 44, then up through upper nozzle section internal through-orifice 54, through nozzle exit orifices 53 and finally exiting out of apertures 52. The depicted embodiment design is shown by way of example and not limitation. It should be noted that although the mandrel shown is solid wall plunger mandrel 20, any other sidewall geometry can be utilized including all aforementioned sidewall geometries. It should also be noted that the size of nozzle exit orifices 53 and apertures 52 control the amount of gas jetting. The other internal orifices such as lower section internal orifice 44A, through internal mandrel orifice 44, and upper nozzle section internal through-orifice 54 can be manufactured in various internal dimensions.

FIG. 6 is a side cross-sectional cut view of liquid aeration plunger 2000 of the present invention during plunger lift. When the surface valves open to start the lift process, down hole pressure will cause gas G to enter the plunger lower entry aperture 48, pass up through all aforementioned internal orifices (44A, 44, 54, 53), exit apertures 52 in directions E, then jet into the liquid load L to form bubbles B in a turbulent fashion. This action results in a transfer of momentum from the jetting gas into the liquid formation. The gaseous jetting, turbulence and aeration of the liquid is a result of the momentum transfer which allows the plunger to carry a heavier than average liquid load to the well top, increasing the load capacity and/or allowing for a faster rise velocity of a given liquid load. The result is an increase in well productivity for wells with high liquid loads.

Injecting a soapy mixture S down to the well bottom between the aforementioned well casing 8 and tubing 9 can assist the momentum transfer process by mixing with gas G and allowing a higher surface tension in the gaseous bubbles B formed when ejecting gas into liquid formation L. Liquid aeration plunger 2000 can easily be manufactured with any existing plunger sidewall geometry.

An additional embodiment of the present invention incorporates a nozzle type aerator in a bypass plunger design, employing the same basic concept of momentum transfer and gaseous aeration of the liquid formation. Bypass plungers typically have an actuator that is in a ‘open’ position during plunger decent to the well bottom and is in a ‘closed’ position during a plunger rise to the well top. Modifications to the actuator rod or to the bypass valve or mandrel housing at the closed interface providing an orifice or an aperture for gas jetting will allow for momentum transfer from the gas to the liquid. The modifications shown herein are by way of example and not limitation.

FIG. 7 shows side views of variable orifice bypass valve (VOBV) 300 of prior art with various aforementioned sidewall geometries; pad plunger mandrel section 60A; brush plunger mandrel section 70A; solid ring plunger mandrel section 20A; and shifting ring plunger mandrel section 80A. Each VOBV is shown in an unassembled state with respect to its unique sidewall geometry mandrel section and a common VOV 300 bottom section and typically has a standard American Petroleum Institute (API) internal fishing neck. Each mandrel section also has hollowed out core 67. Each depicted bottom section is a VOBV 300 shown in its full open (or full bypass) set position. The bypass function allows fluid to flow through during the return trip to the bumper spring with the bypass closing when the plunger reaches the well bottom. The by-pass feature optimizes plunger travel time in high liquid wells. Each VOBV 300 has female internal treaded end 64, which accepts top section male treaded end 66 to unite both sections. The present invention is not limited by the specific design of bypass valve and VOBV is shown only by way of example. Modifications to actuator rod 25 will allow the aforementioned momentum transfer of the present invention and will be described below.

FIG. 8A is a side cross-sectional view of VOBV assembly 300 of prior art with actuator rod 25 shown in the open (or bypass) position. VOBV assembly 300 threaded interface 64 joins to a mandrel section via mandrel threads 66 (FIG. 7). When VOBV assembly 300 arrives at the well top, the aforementioned striker rod within the lubricator hits actuator rod 25 at rod top end 37 moving actuator rod 25 in direction P to its open position. In its open position, the top end of actuator rod 25 rests against variable control cylinder 26 internal surface. Brake clutch 21 will hold actuator rod 25 in its open position allowing well loading (gas/fluids etc.) to enter the open orifice and move up through the hollowed out section of bypass plunger during decent to the well bottom thereby allowing it to optimize its decent to the well bottom as a function of the bypass setting. Access hole 29 is for adjustments to the bypass setting via variable orifice opening 31.

FIG. 8B is a side cross-sectional view of VOBV assembly 300 of prior art and similar to FIG. 8A but with actuator rod 25 depicted in its closed (no bypass) position. When bottom bumper spring striker end 34 hits the well bottom, the actuator rod 25 moves in direction C to a closed position. In the closed position, rod top end 37 with its slant surface 36 closes against treaded top section end 66 and is held in the closed position by brake clutch 21 thus allowing VOBV 300 to be set in a closed bypass condition to enable itself to rise back to the well top.

An additional embodiment of the present invention provides liquid aeration bypass plunger via a modification of a typical bypass valve. It allows one or more small apertures or orifices within the actuator rod to provide gas jetting into the liquid load during the ‘closed’ position of the actuator rod. Thus when in a ‘closed’ position, the bypass plunger will function as previously described via the transfer of momentum and gas jetting causing aeration of the liquid load. Each mandrel section hollowed out core 67 (FIG. 7) will typically have a liquid formation formed within when the plunger is at the well bottom. When the surface valves open to start the lift process, down hole pressure will cause gas to be forced through the actuator rod nozzles, or along the actuator rod seal boundary via cut out grooves, exiting into the liquid load formation and thereby transferring momentum from the gas to the liquid and producing a turbulence and gaseous aeration of the liquid. This action will allow a more efficient lift of the liquid formation to the well top by either increasing the load capacity and/or allowing for a faster rise velocity of a given liquid load.

FIGS. 9, 9A, 9B are side cross-sectional views of examples of possible modifications of actuator rod 25 for the additional embodiment of the present invention. When actuator rod 25 is in a closed position, there is a seal along slant surface 36, which prevents gas flow through the VOBV. The modifications of the additional embodiment of the present invention will allow for small gas exit aperture(s) when modified actuator rods are in a closed position (FIG. 8B). Allowing a portion of gas to exit when in a closed position will cause the aforementioned momentum transfer from the gas into the liquid formation within central hollowed out core 67 (see FIGS. 10, 10A, 10B) and will result in a liquid lift assist in a bypass plunger. The modifications are shown by way of example and not limitation of the present invention.

FIGS. 9, 9C are views of grooved actuator rod 25A with four grooves 94 cut partially into actuator rod top surface 37, into slant surface 36 and down top side surface 39. Four cut grooves are shown by way of example and not limitation. As an example cut grooves also could be cut into the mating sidewall of VOBV/mandrel (not shown) closed position actuator rod interface. Section A-A is a cross-sectional side view of grooved actuator rod 25A. Jetting of gas would pass into the liquid formation within each mandrel section hollowed out core 67 (FIG. 7) via cut out grooves 94. Also shown is an alternate design (dotted lines) with top slant holes 96 which could be drilled from top surface 37 to the just below side surface 39, which would replace the aforementioned cut out grooves 94. Equivalent designs would include a metal burr acting to keep one rod slightly open in the closed position.

FIG. 9A is a side cross sectional view of split orifice actuator rod 25B modified via central orifice 74, and having four connected 450 orifices 76 with exit apertures 78 exiting at actuator rod top surface 37. Gas enters at gas entry aperture 86 located at actuator rod bottom surface 34, moves up through central orifice 74, then through nozzle orifices 76, and exits into the liquid formation from apertures 78 located along actuator rod top surface 37.

FIG. 9B is a side cross-sectional view of center orifice actuator rod 25C with a central thru orifice 84 having a gas entry aperture 86 along actuator rod bottom surface 34 and gas exit aperture 88 at actuator rod top surface 37.

FIGS. 10, 10A, 10B are side cross-sectional views of the additional embodiment of the present invention for a bypass plunger showing various modified aforementioned actuator rods of FIGS. 9, 9A, 9B inserted within a bypass valve assembly. Each design is shown by way of example and not limitation. In each case a limited amount of gas is allowed to exit the seal area of the VOBV when the actuator is in a closed position and when the down hole pressure allows gas to be jetted through the valve. The release of down hole pressure will transfer momentum from the gas into the liquid load, starting within hollowed out core 67, increasing the load capacity and/or allowing for a faster rise velocity of a given liquid load, thus increasing well lift efficiency and productivity.

FIG. 10 is a side cross-sectional view of a VOVB assembly 300A showing aforementioned grooved actuator rod 25A in a closed position within VOBV assembly 300A. When down hole pressure is released, gas will enter variable orifice opening 31 (FIG. 8A) and/or access hole 29 and will jet through cut out grooves 94, transferring momentum in direction GE to liquid formation L within hollowed out core 67 and up through the plunger mandrel into the entire liquid load. This action cause aeration of liquid L and will form bubbles B within liquid load L. Also shown are the top slant holes 96 which could be drilled from top surface 37 to the just below the side surface and which would replace cut out grooves 94.

FIG. 10A is a side cross-sectional view showing split orifice actuator rod 25B in a closed position within VOBV assembly 300B. Split orifice actuator rod 25B is modified via central orifice 74, and having four connected 45° orifices 76 with exit apertures 78 exiting at actuator rod top surface 37. When down hole pressure is released, gas G would enter at gas entry aperture 86 located at actuator rod bottom surface 34, move up through central orifice 74, then through nozzle orifices 76, and exit in direction GE into the liquid formation L from apertures 78 located along actuator rod top surface 37. The transfer of momentum of the gas would cause aeration bubbles B within liquid L of hollowed out core 67 and up through the plunger mandrel into the entire liquid load.

FIG. 10B is a side cross-sectional view showing aforementioned showing center orifice actuator rod 25B in a closed position within VOBV assembly 300C. Center orifice actuator rod 25B has central thru orifice 84. Gas G enters aperture 86 along actuator rod bottom surface 34 and exits out gas exit aperture 88, located along actuator rod top surface 37 at actuator rod top surface 37, in direction GE and into the liquid formation L. The transfer of momentum of gas G into liquid formation L would cause aeration bubbles B within liquid L contained within hollowed out core 67 and up through the plunger mandrel into the entire liquid load.

The actuator rod or side escape of the actuator rod or seal area has at least one exit orifice with a total cross sectional area in the range of about 0.25% to 10% of the maximum plunger cross sectional area. Typically, the smallest range of the cross sectional area of the apertures (or escape area), which exit gas into hollowed out core 67, is about 3.22 mm² to 32.3 mm² (0.005 to 0.05 inch²). As an example, and not a limitation, in FIG. 10A the four nozzle orifices are each typically about 2.36 mm (0.093″) in diameter, combining to about 17.4 mm² (0.027 inch²) of area as compared to the outside diameter of a typical plunger of about 47 mm (1.85″) or about 1735 mm² (2.69 inch²).

Examples shown above in FIGS. 9, 9A, 9B, 10, 10A and 10B are shown by way of example and not limitation for a variable type bypass valve. Modifications to fixed bypass valves, although not specifically shown, can also provide for the gas jetting in a similar manner as described above.

The momentum transfer and resulting liquid turbulence and aeration of the plunger of the present invention allows for improved efficiency and productivity in wells that have high levels of liquid formation. It allows for a more efficient lift of large liquid loads by increasing the plunger lift capacity of a liquid load and/or increasing the lift velocity of a given load via transfer of momentum from down hole gas to the liquid load, functioning to aerate the liquid load during plunger lift. The liquid aeration plunger is easy to manufacture, and easily incorporates into the design into existing plunger geometries. As previously described, applying a soapy mixture down to the well bottom between the well casing and tubing can assist the aeration process by allowing a higher surface tension in the gaseous bubbles formed within the liquid formation.

It should be noted that although the hardware aspects of the of the present invention have been described with reference to the depicted embodiment above, other alternate embodiments of the present invention could be easily employed by one skilled in the art to accomplish the gas momentum aspect of the present invention. For example, it will be understood that additions, deletions, and changes may be made to the orifices, apertures, or other interfaces of the plunger with respect to design other than those described herein.

Although the present invention has been described with reference to the depicted embodiments, numerous modifications and variations can be made and still the result will come within the scope of the invention. No limitation with respect to the specific embodiments disclosed herein is intended or should be inferred. 

1. A plunger comprising: a cylindrical body having an upper and a lower end; an internal longitudinal orifice throughout the plunger's entire length; the upper end having one or more exit apertures to the longitudinal orifice; the lower end having one or more entry apertures to the longitudinal orifice; and wherein a small amount of pressurized gas from a well bottom flows through said longitudinal orifice during a rising of the plunger propelled by down hole pressure and exits the one or more upper end apertures, thereby aerating a liquid formation above it during the rising of the plunger.
 2. The plunger of claim 1, wherein the upper end further comprises an external end having a fish neck design.
 3. The plunger of claim 2, wherein a smallest range of the cross sectional area of either the lower end apertures or the upper end apertures over the internal longitudinal orifice is about 0.005 to 0.05 inch².
 4. (FIG. 5) The plunger of claim 1, wherein the lower end has one entry aperture, and the upper end has at least four apertures.
 5. (FIG. 9C) The plunger of claim 1, wherein the lower end further comprises an actuator rod bypass valve having an open and a closed bypass position, wherein the closed bypass position permits a small amount of pressurized gas therethrough.
 6. (FIG. 9C) The plunger of claim 5, wherein the bypass valve further comprises a grooved actuator rod top surface.
 7. (FIGS. 9A, 9B) The plunger of claim 1, wherein the lower end further comprises an actuator rod bypass valve with a hole through the actuator rod.
 8. (FIGS. 9A, 9B) A bypass plunger comprising: a mandrel portion having an internal longitudinal conduit communicating to at least one exit orifice in a top end of the plunger; a lower end bypass valve assembly connected to a bottom end of the mandrel portion; wherein a falling of the plunger results in the bypass plunger hitting a well stop causing an actuator rod contained within the bypass valve assembly to place the bypass valve assembly in a closed bypass position; said actuator rod having at least one longitudinal internal orifice with at least one exit aperture at its top and at least one entry aperture at its lower end; and wherein when the actuator rod is in the closed bypass position with the bypass plunger rising due to down hole pressure, a stream of gas passes through the actuator rod into the internal longitudinal conduit and out the exit orifice, thereby aerating a liquid formation above the bypass plunger.
 9. The plunger of claim 8, wherein the mandrel portion top end further comprises a fish neck design.
 10. (FIG. 9C)A bypass plunger comprising: a mandrel portion having an internal longitudinal conduit communicating to at least one exit orifice in a top end of the plunger; a lower end bypass valve assembly connected to a bottom end of the mandrel portion; wherein a falling of the plunger results in the bypass plunger hitting a well stop causing an actuator rod contained within the bypass valve assembly to place the bypass valve assembly in a closed bypass position; said actuator rod having a rod top end and mandrel seat which provide a flow through orifice; and wherein when the actuator rod is in the closed bypass position with the bypass plunger rising due to down hole pressure, a stream of gas passes through the flow through orifice into the internal longitudinal conduit and out the exit orifice, thereby aerating a liquid formation above the bypass plunger.
 11. The bypass plunger of claim 10, wherein the top rod end and mandrel seat which provide a flow through orifice further comprise a peripheral groove in the rod top end.
 12. A plunger comprising: a cylindrical body having an upper and a lower end; said body having an internal longitudinal orifice; said lower end having an entry aperture into the internal longitudinal orifice; said upper end having at least one exit orifice with a total cross sectional area in the range of about 0.25% to 10% of the maximum plunger cross sectional area; a mandrel portion having an internal longitudinal conduit communicating to a least one exit orifice in a top end of the plunger; a lower end bypass valve assembly connected to a bottom end of the mandrel portion; wherein a falling of the plunger results in the bypass plunger hitting a well stop causing an actuator rod contained within the bypass valve assembly to place the bypass valve assembly in a closed bypass position; and said actuator rod having at least one longitudinal internal orifice with at least one exit aperture at its top and at lease one entry aperture at its lower end.
 13. A bypass plunger comprising: a mandrel portion having an internal longitudinal conduit communicating to a least one exit orifice in a top end of the plunger; a lower end bypass valve assembly connected to a bottom end of the mandrel portion; wherein a falling of the plunger results in the bypass plunger hitting a well stop causing an actuator rod contained within the bypass valve assembly to place the bypass valve assembly in a closed bypass position; said actuator rod having a rod top end and mandrel seat means functioning to provide a flow through orifice, and functioning so when the actuator rod is in the closed bypass position with the bypass plunger rising due to down hole pressure, a stream of gas passes through the flow through orifice into the internal longitudinal conduit and out the exit orifice, thereby aerating a liquid formation above the bypass plunger. 